Method and system of recovering helium from underground resources

ABSTRACT

The present disclosure describes a method of recovering oil and gas from a helium-containing reservoir generally having some degree of water saturation within the reservoir pore network by injecting a gas into the reservoir. The method is applicable to reservoirs having high water saturation of about 50 percent or greater. High water saturation in a reservoir can cause excessive amounts of water to be produced to produce the helium. Coproduction and management of this water is costly and burdensome to operations leaving many reservoirs of helium stranded, rendering the production uneconomic. The method described herein addresses these needs and other needs.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to U.S. Provisional Patent Application62/666,563, filed 3 May 2018, and U.S. Provisional Patent Application62/673,608, filed 18 May 2018. The entireties of both of theabove-referenced applications are incorporated herein by reference.

FIELD OF THE INVENTION

The following disclosure relates generally to production of helium froma subterranean formation.

BACKGROUND OF THE INVENTION

Underground reservoirs may contain helium, which is often found inassociation with other gases including nitrogen and natural gas.However, the sources for natural gas and helium are different. Naturalgas is sourced from organic matter either through heat, temperature andpressure conditions in a process called thermogenesis or throughbacterial decay of organic matter. Gas formed from bacterial decay oforganic matter is known as biogenic methane. Helium is generated fromradioactive decay of uranium, thorium and their daughter products.Natural gas and helium are produced from independent sources althoughthey are generally found together.

The oil and gas industry employ various methods for identifying naturalgas accumulations in the subsurface. These methods include seismicevaluation, well logging and physical tests that determine the presenceof natural gas. For economic reasons, the industry typically avoidssubsurface formations that hold minor saturation of gases due to theexcessive volumes of saltwater that would accompany such an effort.

Underground reservoirs generally have some degree of water saturationwithin the pore network. Many reservoirs containing helium throughoutthe world have high water saturation (50 percent or greater). Evenreservoirs which produce water-free, or produce only modest volumes ofwater, may have up to 60% or more, water saturation. High watersaturation in a reservoir causes excessive amounts of water to beproduced to produce the helium. Coproduction and management of thiswater is costly and burdensome to operations. For example, expensivedeep injection well facilities may be required. However, some of theseoperations are believed to be responsible for recent earthquake activityand the cause of production curtailments mandated by regulators, imposedon the industry. In some cases, millions of barrels of water areproduced to recover helium and associated gases that otherwise wouldremain in the ground. The reverse of these conditions can also be true,where reservoirs with relatively high gas or oil saturation, produceexcessive volumes of water. The present invention is a method ofrecovering helium from reservoirs that have undesirable volumes ofwater.

SUMMARY OF THE INVENTION

The oil and gas industry employ various methods for identifying naturalgas accumulations in the subsurface. These methods include seismicevaluation, well logging and physical tests that determine the presenceof natural gas. For economic reasons, the industry typically avoidssubsurface formations that hold minor saturation of gases due to theexcessive volumes of saltwater that would accompany such an effort.

In addition, subsurface formations (including aquifers) can contain lowBritish thermal unit (BTU) or no BTU gas (e.g., nitrogen) together withhelium. For example, such formations may include a mixture of gases thatincludes helium but is mostly nitrogen; however, it may not beeconomically feasible to extract gases such as helium from suchformations using conventional methods. These and other needs areaddressed by the present disclosure. Aspects of the present disclosurecan have advantages over current practices.

The present disclosure provides methods and systems for recovery forhelium and associated other gases mixed in composition by injecting aprovided gas (e.g., nitrogen) into subsurface formations. Native gastrapped as a discontinuous phase coalesces with the injected providedgas (e.g., nitrogen) becoming enriched in native gas compositionsincluding helium. For example, nitrogen gas and helium gas trapped as adiscontinuous phase coalesce with the injected nitrogen becoming acoalesced gas of nitrogen and helium. Native gas may include undergroundor subterranean areas of gas, including natural gas within a producingreservoir when the reservoir is converted into a gas-storage reservoir.Native gas may include coalbed methane (CBM), coalbed gas, coal seam gas(CSG), or coal-mine methane (CMM). Thus, native gas compositions caninclude not only helium but also components of natural gas,hydrocarbons, nitrogen, and carbon dioxide. In addition, native gascompositions can include only nitrogen and helium. The gas is thenallowed to produce back into a well for collection and processing. Theprocess may be repeated until the gas composition meets an economiclimit of recovery as determined by the rate of gas, volume of gas andcomposition of the commingled gases.

The working mechanisms of these methods can include formation of acontinuous gas phase by adding gas volume, diffusion of varyingcomposition of gases and partitioning of native gas into the injectedprovided gas (e.g., nitrogen) assisted by partial pressure drive.

Injected nitrogen may be either manufactured onsite or developed throughwells tapping naturally occurring nitrogen deposits. The nitrogen (e.g.,naturally occurring nitrogen) may flood into partially saturated heliumaquifers. The flooding can occur naturally and/or by injection of aprovided gas that includes nitrogen.

The specific injection and production cycles may be in the same wellboreusing a ‘huff and puff’ method, or through separate injection andproduction wells such as is typical of a waterflood configuration.

For wells with multiple, stacked, subsurface formations containingnative gas, the process may be repeated so that with each injection, theproduced gas is enriched each time prior to recovery of helium.

The present disclosure provides a method that can include providing aprovided gas, injecting the provided gas into a helium-containingreservoir, ceasing the injection of the provided gas, and gathering fromthe helium-containing reservoir a mixture of the provided gas and someof the gaseous helium from the helium-containing reservoir. Thehelium-containing reservoir may contain water and may be a partiallysaturated aquifer. For example, the helium-containing reservoir may be apartially saturated aquifer containing a majority of nitrogen gas with aminority of helium gas.

The present disclosure provides a method that can include: providing agas; injecting the provided gas into a selected well bore in fluidcommunication with a helium-containing reservoir having a firstwater-to-gas production ratio, where the helium-containing reservoircomprises a gaseous helium, where the provided gas is injected at rateof from about 10 thousand cubic feet per day (mcfd) or more to about nomore than about 8,000 mcfd, and where at least most of the heliumproduced through (or via) the well bore is a gaseous helium; ceasing theinjection of the provided gas into the selected well bore; gatheringtogether from the helium-containing reservoir by the selected well boresome of the provided gas and some of the gaseous helium to form agathered-gas mixture comprising the provided gas and some of the gaseoushelium from the helium-containing reservoir, and producing through theselected well bore the gathered-gas mixture, where the helium-containingreservoir producing the gathered-gas mixture has a second water-to-gasproduction ratio and where the second water-to-gas ratio is no more thanthe first water-to-gas ratio.

The present disclosure provides a method that can include: providing awell having first water to gas production ratio; providing a gas;injecting the provided gas into a well bore, where the well boretraverses and/or is in fluid communication with a helium-containingreservoir, where the helium-containing reservoir comprises a gaseoushelium; ceasing the injection of the provided gas; and producing fromthe well bore a mixture of the provided gas and some of the gaseoushelium having a second water to gas production ratio, where the firstwater-to-gas ratio is greater than the second water-to-gas ratio.

If the gaseous helium is in a discontinuous phase (e.g., helium is inliquid entrapment), then helium produced from the well bore in theproducing step may be at least most gaseous helium. Further, if thenative gas is in a discontinuous phase, then helium produced from thewell bore in the producing step may be at least most gaseous helium.

If the gaseous nitrogen and the gaseous helium is in a discontinuousphase (e.g., nitrogen in liquid entrapment and helium in liquidentrapment), then gases produced from the well bore in the producingstep may be at least most gaseous nitrogen and helium. Further, if thenative gas is in a discontinuous phase, then gases produced from thewell bore in the producing step may be at least most gaseous nitrogenand helium. In various embodiments of the present disclosure, thehelium-containing reservoir may contain only nitrogen gas and helium gas(e.g., the helium-containing reservoir may not contain any othercomponents of natural gas).

The present disclosure provides a method that can include: providing atarget well having a first water to gas production ratio from about 1bbl water/1000 thousand cubic feet (MCF) to about 2000 bbl water/1000MCF; providing a gas; injecting the provided gas into a well bore, wherethe well bore traverses and/or is in fluid communication with thehelium-containing reservoir, where the provided gas is injected at arate of from about 10 mcfd or more to about no more than about 8,000mcfd; and producing, after the ceasing of the injection of the providedgas, from the target well at a second water to gaseous helium ratio,where the second water to gaseous helium ratio is from about 98% toabout 2% of first water to gas production ratio and where at least mostof the helium produced from the well bore in the producing step is agaseous helium.

The helium-containing reservoir commonly has a moveable water saturationvalue from about 15% to about 90%.

The provided gas can be injected at a rate of from about 10 mcfd or moreto about no more than about 8,000 mcfd. Commonly, the provided gas istypically injected for a period from about five days to about threemonths.

The gathered gas can comprise a mixture of the provided gas and thehelium gas having from about 2 to about 98 volume % of the provided gasand from about 98 to about 2 volume % of the helium gas. The gatheredgas can comprise a mixture of the provided gas and the helium gas havingfrom about 1 to about 99 volume % of the provided gas and from about 99to about 1 volume % of the helium gas.

The gathered gas can comprise a mixture of the provided gas and thehelium gas having from about 1 to about 99 volume % of nitrogen and fromabout 99 to about 1 volume % of helium. The gathered gas can comprise amixture of about 99% nitrogen gas and less than about 1% helium gas. Forexample, the gathered gas can comprise a mixture of about 99% nitrogengas and about 0.7% helium gas. The gathered gas can comprise a mixtureof about 99% nitrogen gas and about 0.5% helium gas. The gathered gascan comprise a mixture of only helium gas and nitrogen gas. The gatheredgas can comprise about 1% or less of helium gas, with the remaining gasbeing nitrogen gas. The provided gas injected into the helium-containingreservoir can be selected from the group consisting of methane, ethane,propane, nitrogen, butane, air, oxygen, argon, carbon dioxide, andmixtures thereof.

The helium-containing reservoir can comprise, prior to the injecting ofthe provided gas, a plurality of discrete helium phases. Further, thehelium-containing reservoir can comprise, in addition to amounts ofhelium, discrete nitrogen phases. The plurality of discrete heliumphases and the plurality of discrete nitrogen phases can be in the formof one or more pockets and bubbles of helium and one or more pockets andbubbles of nitrogen. During the injecting of the provided gas, theprovided gas (e.g., nitrogen) and one or more of the plurality ofdiscrete helium phases may coalesce to form one or more continuousphases of provided gas and helium (e.g., one or more continuous phasesof nitrogen and helium). The one or more continuous phases of nitrogenand helium may be a coalesced amount of nitrogen and helium.

The helium-containing reservoir can comprise, prior to the injecting ofthe provided gas, a plurality of discrete helium phases, although mostof the helium may reside mostly in a gas phase due to the low solubilityof helium in water. The plurality of discrete helium phases can be inthe form of one or more pockets and bubbles of helium. The injecting ofthe provided gas can coalesce the one or more of the plurality ofdiscrete helium phases into one or more continuous helium phases. Theinjection of the provided gas can reduce the level of water saturationfrom about 5 to about 95%.

The gathering step can be continued until one or more of the followingis true: (i) the production of the mixture of the provided gas and thegaseous helium from the hydrocarbon-containing reservoir ceases; and(ii) the helium-containing reservoir becomes water saturated andproduces primarily water. The provided gas can be one of air, nitrogen,methane, or a mixture thereof. The gaseous helium can comprise one ormore of natural gases, nitrogen, and carbon dioxide.

In accordance with the present disclosure, a method can include:providing a provided gas, injecting the provided gas into a well bore,ceasing the injection of the provided gas, and producing from the wellbore a mixture of the provided gas and some of the gaseous helium fromthe helium-containing reservoir. The well bore can traverse ahelium-containing reservoir having a moveable water saturation valuefrom about 5% to about 95%.

The gathered gas can comprise a mixture of the provided gas and thegaseous helium having from about 2 to about 98 volume % the provided gasand from about 98 to about 2 volume % the gaseous helium. The gatheredgas can comprise a mixture of the provided gas and the helium gas havingfrom about 1 to about 99 volume % of the provided gas and from about 99to about 1 volume % of the helium gas. The gathered gas can comprise amixture of the provided gas and the helium gas having from about 1 toabout 99 volume % of nitrogen and from about 99 to about 1 volume % ofhelium.

Typically, the helium-containing reservoir can have pore volumes havinga porosity and permeability. The helium-containing reservoir can have,prior to the injecting of the provided gas, a plurality of discretehelium phases contained within the pore volumes. The injecting of theprovided gas can coalesce the one or more of the plurality of discretehelium phases into one or more continuous helium phases. The one or morecontinuous helium phases can span three or more pore volumes.

The injection of the provided gas can reduce the level of watersaturation from about 2 to about 98%. The provided gas injected into thehelium-containing reservoir can be one of methane, ethane, propane,nitrogen, butane, air, oxygen, argon, carbon dioxide or mixture thereof.The injecting of the gas into the well bore is generally at a pressurebelow the fracture pressure of the helium-containing reservoir.

Commonly, the producing step can be continued until one or more of thefollowing is true: (i) the production of the mixture of the provided gasand some of the gaseous helium from the helium-containing reservoirceases; and (ii) the helium-containing reservoir becomes water saturatedand produces primarily water. The provided gas is typically injectedinto the helium-containing reservoir at rate of from about 10 mcfd ormore to about no more than about 1,000 mcfd. The injecting of theprovided gas can be for a period from about five days to about threemonths.

The present disclosure provides a method that can include: providing aprovided gas, injecting the provided gas into a well bore, producing,after the ceasing of the injection of the provided gas, from the wellbore a mixture of the provided gas and some of the gaseous helium fromthe helium-containing reservoir. The well bore typically traverses ahelium-containing reservoir comprising a gaseous helium. The providedgas is generally injected at rate of from about 10 mcfd or more to aboutno more than about 8,000 mcfd. The injecting of the provided gas can befor a period from about five days to about three months. Moreover, thegathered gas can usually comprise a mixture of the provided gas and thegaseous helium having from about 2 to about 98 volume % the provided gasand from about 98 to about 2 volume % the gaseous helium. Thehelium-containing reservoir can have a moveable water saturation valuefrom about 5% to about 95%. The provided gas injected into thehelium-containing reservoir can be one of methane, ethane, propane,nitrogen, butane, air, oxygen, carbon dioxide or mixture thereof. Theinjecting of the provided gas into the well bore can be at a pressurebelow the fracture pressure of the helium-containing reservoir.

The present disclosure provides a method that includes: providing aprovided gas, injecting the provided gas into a helium-containingreservoir having a first water to gas production ratio, ceasing theinjection of the provided gas, and gathering from the helium-containingreservoir a gathered-gas mixture comprising the provided gas and some ofthe gaseous helium from the helium-containing reservoir. Thehelium-containing reservoir can comprise a gaseous helium. Moreover, theprovided gas can typically be injected at rate of from about 10 mcfd ormore to about no more than about 8,000 mcfd. The helium-containingreservoir producing the gathered-gas mixture can commonly have a secondwater to gas production ratio and where the second water-to-gas ratio isno more than the first water-to-gas ratio. The provided gas injectedinto the helium-containing reservoir can be selected from the groupconsisting of methane, ethane, propane, nitrogen, butane, air, oxygen,argon, carbon dioxide, and mixtures thereof. The helium-containingreservoir can commonly have, prior to the injecting of the provided gas,a plurality of discrete helium phases. The plurality of discrete heliumphases can usually be in the form of one or more pockets and bubbles ofhelium. The injecting of the provided gas can coalesce the one or moreof the plurality of discrete helium phases into one or more continuoushelium phases. The gathered gas mixture can comprise the provided gasand the gaseous helium having from about 2 to about 98 volume % theprovided gas and from about 98 to about 2 volume % the gaseous helium.The gaseous helium can be mixed with one of methane, ethane, propane,n-butane, isobutane, ethylene, propylene, 1-butene, and mixturesthereof. The first water to gaseous helium is commonly from about 1 bblwater/1000 MCF to about 2000 bbl water/1000 MCF. The second water togaseous helium ratio is generally from about 98% to about 2% of firstwater to gaseous helium ratio. The injecting of the provided gas istypically for a period from about five days to about three months.

The present disclosure provides a method that can include: providing awell having first water to gas production ratio. providing a providedgas, injecting the provided gas into a well bore, ceasing the injectionof the provided gas, and producing from the well bore a mixture of theprovided gas and some of the gaseous helium having a second water to gasproduction ratio. The well bore typically traverses a helium-containingreservoir. The helium-containing reservoir can comprise a gaseoushelium. The first water-to-gas ratio is usually greater than the secondwater-to-gas ratio. The helium-containing reservoir can have porevolumes having a porosity and permeability. The helium-containingreservoir can have, prior to the injecting of the provided gas, aplurality of discrete helium phases contained within the pore volumes.The injecting of the provided gas can coalesce one or more of theplurality of discrete helium phases into one or more continuous heliumphases. Generally, the one or more continuous helium phases can spanthree or more pore volumes. Commonly, the first water to gaseous heliumcan be from about 1 bbl water/1000 MCF to about 2000 bbl water/1000 MCF.Generally, the provided gas injected into the helium-containingreservoir can be one of methane, ethane, propane, nitrogen, butane, air,oxygen, argon, carbon dioxide or mixture thereof. Typically, theinjecting of the gas into the well bore can be at a pressure below thefracture pressure (“press”) of the helium-containing reservoir. Thesecond water to gaseous helium ratio can be from about 98% to about 2%of first water to gaseous helium ratio. The mixture of the provided gasand some of the gaseous helium can have from about 2 to about 98 volume% the provided gas and from about 98 to about 2 volume % the gaseoushelium. Commonly, the injecting of the provided gas can be for a periodfrom about five days to about three months.

The present disclosure can provide a method that can include: providinga target well having a first water to gas production ratio from about 1bbl water/1000 MCF to about 2000 bbl water/1000 MCF, providing aprovided gas, injecting the provided gas into a well bore, andproducing, after the ceasing of the injection of the provided gas, fromthe target well at a second water to gaseous helium ratio. The well boreusually traverses the helium-containing reservoir. The provided gas istypically injected at a rate of from about 10 mcfd or more to about nomore than about 8,000 mcfd. The second water to gaseous helium ratio iscommonly from about 98% to about 2% of first water to gas productionratio. The provided gas injected into the helium-containing reservoircan be one of methane, ethane, propane, nitrogen, butane, air, oxygen,argon, carbon dioxide or mixture thereof. The injecting of the providedgas into the well bore can be at a pressure below the fracture press ofthe helium-containing reservoir.

It is one aspect of the present invention to provide a method,comprising injecting a provided gas into a well bore in fluidcommunication with a helium-containing reservoir; ceasing the injectionof the provided gas into the selected well bore; and gathering togetherfrom the helium-containing reservoir by the selected well bore some ofthe provided gas and some of the helium to form a gathered-gas mixturecomprising the provided gas and some of the helium from thehelium-containing reservoir; and producing through the selected wellbore the gathered-gas mixture.

In embodiments, the helium-containing reservoir may have a moveablewater saturation value of between about 15% and about 90%.

In embodiments, the provided gas may be injected into the well bore at arate of between about 10 mcfd and about 8,000 mcfd.

In embodiments, the gathered-gas mixture may comprise between about 0.5vol % and about 99.5 vol % of the provided gas and between about 0.5 vol% and about 99.5 vol % of helium.

In embodiments, the provided gas injected into the helium-containingreservoir may be selected from the group consisting of methane, ethane,propane, nitrogen, butane, air, oxygen, argon, carbon dioxide, andmixtures thereof.

In embodiments, the helium-containing reservoir may comprise at leastone of a plurality of discrete helium phases and a plurality of discretenitrogen phases prior to the injecting of the provided gas. Where thehelium-containing reservoir comprises a plurality of discrete heliumphases prior to the injecting of the provided gas, the provided gas andone or more of the plurality of discrete helium phases may, but neednot, coalesce to form one or more continuous phases of the provided gasand helium during the injecting of the provided gas.

It is another aspect of the present invention to provide a method,comprising providing a gas; injecting the provided gas into a selectedwell bore in fluid communication with a helium-containing reservoirhaving a first water-to-gas production ratio, wherein the provided gasis injected at rate of from about 10 mcfd or more to about no more thanabout 8,000 mcfd; ceasing the injection of the provided gas into theselected well bore; gathering together from the helium-containingreservoir by the selected well bore some of the provided gas and some ofthe gaseous helium to form a gathered-gas mixture comprising theprovided gas and some of the gaseous helium from the helium-containingreservoir; and producing through the selected well bore the gathered-gasmixture, wherein the helium-containing reservoir producing thegathered-gas mixture has a second water-to-gas production ratio andwherein the second water-to-gas ratio is no more than the firstwater-to-gas ratio.

In embodiments, the helium-containing reservoir may have a moveablewater saturation value of between about 15% and about 90%.

In embodiments, the provided gas injected into the helium-containingreservoir may be selected from the group consisting of methane, ethane,propane, nitrogen, butane, air, oxygen, argon, carbon dioxide, andmixtures thereof.

In embodiments, the gathered-gas mixture may comprise between about 0.5vol % and about 99.5 vol % of the provided gas and between about 0.5 vol% and about 99.5 volume % of helium.

In embodiments, the helium-containing reservoir may comprise at leastone of a plurality of discrete helium phases and a plurality of discretenitrogen phases prior to the injecting of the provided gas. Where thehelium-containing reservoir comprises a plurality of discrete heliumphases prior to the injecting of the provided gas, the provided gas andone or more of the plurality of discrete helium phases may, but neednot, coalesce to form one or more continuous phases of the provided gasand helium during the injecting of the provided gas, and/or a majorityof the helium in the plurality of discrete helium phases may, but neednot, be in a gas phase.

It is another aspect of the present invention to provide a method,comprising providing a target well having a first water to gasproduction ratio from about 1 bbl water/1000 MCF to about 2000 bblwater/1000 MCF; providing a gas; injecting the provided gas into a wellbore, wherein the well bore traverses and is in fluid communication witha helium-containing reservoir, wherein the provided gas is injected at arate of from about 10 mcfd or more to about no more than about 8,000mcfd; and producing, after the ceasing of the injection of the providedgas, from the target well at a second water to gaseous helium ratio,wherein the second water to gaseous helium ratio is from about 98% toabout 2% of first water to gas production ratio.

In embodiments, the helium-containing reservoir may have a moveablewater saturation value of between about 15% and about 90%.

In embodiments, the gathered-gas mixture may comprise between about 0.5vol % and about 99.5 vol % of the provided gas and between about 0.5 vol% and about 99.5 vol % of helium. In embodiments, the provided gasinjected into the helium-containing reservoir may be selected from thegroup consisting of methane, ethane, propane, nitrogen, butane, air,oxygen, argon, carbon dioxide, and mixtures thereof. The injecting ofthe provided gas into the well bore may, but need not, be at a pressurebelow the fracture pressure of the helium-containing reservoir, and atleast about 75 mole % of the production from the well bore immediatelybefore and after provided gas injection may, but need not, be helium.

In embodiments, the helium-containing reservoir may comprise at leastone of a plurality of discrete helium phases and a plurality of discretenitrogen phases prior to the injecting of the provided gas.

Several variations and modifications of the disclosure can be used. Itwould be possible to provide for some features of the disclosure withoutproviding others.

These and other advantages will be apparent from the disclosure of theaspects, embodiments, and configurations contained herein.

As used herein, “at least one”, “one or more”, and “and/or” areopen-ended expressions that are both conjunctive and disjunctive inoperation. For example, each of the expressions “at least one of A, Band C”, “at least one of A, B, or C”, “one or more of A, B, and C”, “oneor more of A, B, or C” and “A, B, and/or C” means A alone, B alone, Calone, A and B together, A and C together, B and C together, or A, B andC together. When each one of A, B, and C in the above expressions refersto an element, such as X, Y, and Z, or class of elements, such asX₁-X_(n), Y₁-Y_(m), and Z₁-Z₀, the phrase is intended to refer to asingle element selected from X, Y, and Z, a combination of elementsselected from the same class (e.g., X₁ and X₂) as well as a combinationof elements selected from two or more classes (e.g., Y₁ and Z_(o)).

It is to be noted that the term “a” or “an” entity refers to one or moreof that entity. As such, the terms “a” (or “an”), “one or more” and “atleast one” can be used interchangeably herein. It is also to be notedthat the terms “comprising”, “including”, and “having” can be usedinterchangeably.

As used herein, the phrase “gaseous helium” or “gas-phase helium”generally refers to helium.

As used herein, the phrase “gaseous hydrocarbon” or “gas-phasehydrocarbon” generally refers to an organic compound having a vaporpressure of about 10 mm Hg at a temperature from about −250 to about −80degrees Celsius. Non-limiting examples of gaseous compounds are organiccompounds from about 1 to about 4 carbon atoms. Non-limiting examples ofsuch organic compounds are methane, ethane, propane, n-butane,isobutane, ethylene, propylene, and 1-butene. Natural gas is an exampleof a gaseous hydrocarbon.

The term “means” as used herein shall be given its broadest possibleinterpretation in accordance with 35 U.S.C., Section 112, Paragraph 6.Accordingly, a claim incorporating the term “means” shall cover allstructures, materials, or acts set forth herein, and all the equivalentsthereof. Further, the structures, materials or acts and the equivalentsthereof shall include all those described in the summary of theinvention, brief description of the drawings, detailed description,abstract, and claims themselves.

As used herein, “natural gas” is a naturally occurring mixture, ornatural mixture, consisting mainly of methane, a compound with onecarbon atom and four hydrogen atoms, but also usually including smallamounts of other hydrocarbon gas liquids and non-hydrocarbon gases. Theother hydrocarbon gas liquids commonly include varying amounts ofhydrocarbons having two or more carbon atoms varying number of hydrogenatoms. The nonhydrocarbon gas generally include small percentages (byweight, volume, and/or moles) of carbon dioxide, nitrogen, hydrogensulfide, and/or helium.

As used herein, “shale” refers to a fine-grained sedimentary rock thatforms from the compaction of silt and clay-size mineral particles thatis commonly called “mud.” This composition places shale in a category ofsedimentary rocks known as “mudstones.” Shale is distinguished fromother mudstones because it is fissile and laminated. “Laminated” meansthat the rock is made up of many thin layers. “Fissile” means that therock readily splits into thin pieces along the laminations.

Unless otherwise noted, all component or composition levels are aboutthe active portion of that component or composition and are exclusive ofimpurities, for example, residual solvents or by-products, which may bepresent in commercially available sources of such components orcompositions.

Every maximum numerical limitation given throughout this disclosure isdeemed to include each lower numerical limitation as an alternative, asif such lower numerical limitations were expressly written herein. Everyminimum numerical limitation given throughout this disclosure is deemedto include each higher numerical limitation as an alternative, as ifsuch higher numerical limitations were expressly written herein. Everynumerical range given throughout this disclosure is deemed to includeeach narrower numerical range that falls within such broader numericalrange, as if such narrower numerical ranges were all expressly writtenherein. By way of example, the phrase from about 2 to about 4 includesthe whole number and/or integer ranges from about 2 to about 3, fromabout 3 to about 4 and each possible range based on real (e.g.,irrational and/or rational) numbers, such as from about 2.1 to about4.9, from about 2.1 to about 3.4, and so on.

The preceding is a simplified summary of the disclosure to provide anunderstanding of some aspects of the disclosure. This summary is neitheran extensive nor exhaustive overview of the disclosure and its variousaspects, embodiments, and configurations. It is intended neither toidentify key or critical elements of the disclosure nor to delineate thescope of the disclosure but to present selected concepts of thedisclosure in a simplified form as an introduction to the more detaileddescription presented below. As will be appreciated, other aspects,embodiments, and configurations of the disclosure are possibleutilizing, alone or in combination, one or more of the features setforth above or described in detail below. Also, while the disclosure ispresented in terms of exemplary embodiments, it should be appreciatedthat individual aspects of the disclosure can be separately claimed.

BRIEF DESCRIPTION OF THE DRAWINGS

The accompanying drawings are incorporated into and form a part of thespecification to illustrate several examples of the presentinvention(s). These drawings, together with the description, explain theprinciples of the invention(s). The drawings simply illustrate preferredand alternative examples of how the invention(s) can be made and usedand are not to be construed as limiting the invention(s) to only theillustrated and described examples. Further features and advantages willbecome apparent from the following, more detailed, description of thevarious embodiments of the invention(s), as illustrated by the drawingsreferenced below.

FIG. 1 depicts a cross-section of a helium-containing reservoir with thefluids omitted according to some embodiments of present disclosure;

FIG. 2 depicts a cross-section of a helium-containing reservoircontaining fluids according to some embodiments of the presentdisclosure;

FIG. 3 depicts a cross-section of a helium-containing reservoircontaining fluids according to some embodiments of the presentdisclosure;

FIG. 4 depicts a process according to some embodiments of the presentdisclosure;

FIG. 5 depicts a cross-section of a helium-containing reservoircontaining fluids according to some embodiments of the presentdisclosure;

FIG. 6 depicts a method of recovering helium from a helium-containingreservoir according to some embodiments of the present disclosure; and

FIG. 7 depicts coalescence of two gases according to some embodiments ofthe present disclosure.

DETAILED DESCRIPTION OF THE INVENTION

These and other needs are addressed by the present disclosure.

FIG. 1 depicts a cross-section of a helium-containing reservoir 100 withthe fluids omitted. The reservoir comprises a plurality of pore volumes120 defined by reservoir mineral material 110.

The helium-containing reservoir can compose one or more of helium,petroleum, and gas. The helium-containing reservoir comprises helium tobe recovered. By way of example, the helium content of thehelium-containing reservoir can be more than about mole 50% gas-phasehelium, more typically at least about 55 mole % gas-phase helium, moretypically at least about mole 60% gas-phase helium, more typically atleast about 65 mole % gas-phase helium, more typically at least about 70mole % gas-phase helium, more typically at least about mole 75%gas-phase helium, more typically at least about 85 mole % gas-phasehelium, more typically at least about mole 90% gas-phase helium, moretypically at least about 95 mole % gas-phase helium, and even moretypically at least about 99 mole % gas-phase helium.

In some embodiments, the helium-containing reservoir comprises naturalgas in addition to the helium. By way of example, the hydrocarboncontent of the helium-containing reservoir can be less than about mole50% gas-phase hydrocarbons, more typically less than about 45 mole %gas-phase hydrocarbons, more typically less than about mole 40%gas-phase hydrocarbons, more typically less than about 35 mole %gas-phase hydrocarbons, more typically less than about 30 mole %gas-phase hydrocarbons, more typically less than about mole 25%gas-phase hydrocarbons, more typically less than about 15 mole %gas-phase hydrocarbons, more typically less than about mole 10%gas-phase hydrocarbons, more typically less than about 5 mole %gas-phase hydrocarbons, and even more typically less than about 1 mole %gas-phase hydrocarbons. By way of another example, the helium-containingreservoir can commonly have a carbon content of less than about 50 mole% of the carbon comprising methane and other hydrocarbon gas liquids,more commonly less than about 45 mole % of the carbon comprising methaneand other hydrocarbon gas liquids, even more commonly less than about 40mole % of the carbon comprising methane and other hydrocarbon gasliquids, yet even more commonly less than about 35 mole % of the carboncomprising methane and other hydrocarbon gas liquids, still yet evenmore commonly less than about 30 mole % of the carbon comprising methaneand other hydrocarbon gas liquids, still yet even more commonly lessthan about 25 mole % of the carbon comprising methane and otherhydrocarbon gas liquids, still yet even more commonly less than about 20mole % of the carbon comprising methane and other hydrocarbon gasliquids, still yet even more commonly less than about 15 mole % of thecarbon comprising methane and other hydrocarbon gas liquids, still yeteven more commonly less than about 10 mole % of the carbon comprisingmethane and other hydrocarbon gas liquids, still yet even more commonlyless than about 5 mole % of the carbon comprising methane and otherhydrocarbon gas liquids, and yet still even more commonly less thanabout 1 mole % of the carbon comprising methane and other hydrocarbongas liquids. It can be appreciated that carbon dioxide is not ahydrocarbon gas liquid.

An example of a helium-containing reservoir is a gas shale reservoir.Shale gas refers to natural gas that is trapped substantially within ashale formation. Conventional gas reservoirs are created when naturalgas migrates toward the Earth's surface from an organic-rich sourceformation into highly permeable reservoir rock, where it is trapped byan overlying layer of impermeable rock. In contrast, shale gas resourcesform within the organic-rich shale source rock. The low permeability ofthe shale greatly inhibits the gas from migrating to more permeablereservoir rocks. Helium may be present in such reservoirs and may bemixed with other gases within the reservoir. Economically significantvolumes of helium may exist in helium-containing reservoirs even if theoverall gas saturation level in the helium-containing reservoir isconsidered low by oil and gas industry standards. Typically, oil and gasindustry standards for sub commercial natural gas saturation are aboutless than 50% of gas saturation, 50% water saturation. Methods andsystems disclosed herein may advantageously allow helium to be producedfrom helium-containing reservoirs where shale gas production (or heliumproduction) would not otherwise be economically feasible.

A helium-containing reservoir is generally considered to be one of waterwet or hydrocarbon wet. More generally, a helium-containing reservoir iswater wet. In a water wet reservoir, water typically coats at leastmost, if not substantially all the surfaces comprising the pores. Moretypically, water coats at least about 50%, if not substantially about100% of the pores surfaces comprising the water wet reservoir. The wateris generally held in place by surface tension. As such, water coatingthe surface of the pores typically does not move while the helium isbeing produced. It can be appreciated, that the production of the heliumcan change the water saturation of the helium-containing reservoir. Thedegree of change of the water saturation generally varies with themethod of production of the helium.

A helium-containing reservoir generally comprises pores and one or moreof a mean, mode and average pore volume, commonly referred to herein asreservoir pore volume. Moreover, the helium-containing reservoircommonly has a porosity and permeability. Each pore generally contains afluid. More generally, each pore contains one of water, helium, ormixture thereof. Saturation of any fluid in a pore space is the ratio ofthe volume of the fluid to pore space volume. That is, the degree ofwater saturation of the helium-containing reservoir generally expressedas the ratio of water volume to pore volume. For example, a watersaturation of 25% corresponds to one-quarter of pore space being filledwith water and the remaining 75% of the pore being with another fluid,such as a liquid, helium gas, or with a fluid other than water, such ascarbon dioxide, nitrogen, or such. In some embodiments, the other fluidcan be a provided hydrogen, that is a hydrocarbon gas introduced intothe helium-containing reservoir by injection through the wellhead.Hydrocarbon saturation is commonly expressed as ratio of hydrocarbonvolume to pore volume, or more commonly as one minus the watersaturation. Helium saturation is commonly expressed as ratio of heliumvolume to pore volume, or more commonly as one minus the watersaturation. The degree of water saturation can be calculated from theeffective porosity and the resistivity logs.

Typically, water contained within a pore can be one of moveable waterand substantially immoveable water. The substantially immoveable watercomprises the water the wetting the surfaces of the pore volume. Thewetted water is generally a film of water covering each pore surface.The substantially immoveable water contained in a helium-containingreservoir is generally not withdrawn during production of the reservoir.Moveable water is the contained with the pore that is not wetting thesurfaces of the pore volume. Moreover, the moveable water generallymoves from one pore to another during production of the reservoir. Assuch, the moveable water can be in some instances produced during heliumproduction of the reservoir.

Moreover, the helium-containing reservoir can have some degree of watersaturation within reservoir pore network. While not wanting to belimited by example, the injection gas can comprise natural gas, nitrogenor in some cases air. When the helium-containing reservoir is composedof high volumes of water, the helium is generally disconnected and/ordiscontinuously distributed through the reservoir. The helium commonlyexists in the reservoir as one or more of helium pockets or bubbles. Thehelium is usually stranded in one or more pores and cracks within thereservoir. Moreover, water generally surrounds the one or more heliumpockets and bubbles.

Currently, the helium and water are produced together. The mechanism ofthe coproduction of the helium and water is believed to work due to oneor both water production carrying the helium along with the water andproduction of water lowering the reservoir pressure causing helium toexpand to have one or more of pocket and/or bubbles coalesce to form afirst continuous phase. In some cases, industry sees increasing gas towater volume to volume ratios under production of high volumes of water.This is due to the expansion behavior of gas compared to gas, hence theincrease in the gas volume to water volume ratio over time as reservoirpressures drop.

FIG. 2 depicts a cross-section of a helium-containing reservoir 100having a continuous helium phase 135 and a plurality of discrete heliumphases 137. The continuous helium phase 135 can be one or more of incontact with and span about four or more pore volumes 120. The discretehelium phases 137 are generally dispersed in a continuous, moveablewater phase 140. The continuous, moveable water phase 140 can be one ormore of in contact with and span about four or more pore volumes 120. Itcan be appreciated that the continuous helium phase 135 and thecontinuous, moveable helium phases 137 are one or more in contact withand span different four or more pore volumes 120. Production of such areservoir typically produces substantially water and substantiallylittle, if any, helium.

FIG. 3 depicts a cross-section of a helium-containing reservoir 100having a substantially depleted helium continuous phase 138 andsubstantially comprising a plurality of discrete helium phases 137. Theplurality of discrete helium phases 137 are typically dispersed in watersaturated helium reservoir. More typically, production from a watersaturated helium reservoir containing a plurality of discrete heliumphases 137 comprises substantially moveable saturated water 140. Evenmore typically, production from reservoirs with high moveable watersaturation values can comprise substantially more water than helium. Insome embodiments, the helium-containing reservoir 100 can commonly havea moveable water saturate level of from one of about 2% or more, morecommonly of about 5% or more, even more commonly of about 10% or more,yet even more commonly of about 20% or more, still yet even morecommonly about 30% or more, still yet even more commonly about 40% ormore, still yet even more commonly about 50% or more, still yet evenmore commonly about 50% or more, or yet even more commonly about 60% ormore to generally one of no more than about 10%, more generally of nomore than about 20%, even more generally of no more than about 30%, yeteven more generally of no more than about 40%, still yet even moregenerally of no more than about 50%, still yet even more generally of nomore than about 60%, still yet even more generally of no more than about70%, still yet even more generally of no more than about 80%, still yeteven more generally of no more than about 90%, still yet even moregenerally of no more than about 92%, still yet even more generally of nomore than about 95%, or yet still even more generally of no more thanabout 98%. Commonly, reservoirs having a high moveable water saturationvalue of one of between about 2%, more commonly about 5%, even morecommonly about 10%, yet even more commonly about 15%, still yet evenmore commonly about 20%, still yet even more commonly about 25%, stillyet even more commonly about 30%, still yet even more commonly about35%, still yet even more commonly about 40%, still yet even morecommonly about 45%, still yet even more commonly about 50%, still yeteven more commonly about 55%, still yet or yet still even more commonlyabout 60% and one of typically about 15%, more typically about 20%, evenmore typically about 25%, yet even more typically about 30%, still yeteven more typically about 35%, still yet even more commonly about 40%,still yet even more commonly about 45%, still yet even more commonlyabout 50%, still yet even more commonly about 55%, still yet even morecommonly about 60%, still yet even more commonly about 65%, still yeteven more commonly about 70%, still yet even more commonly about 75%,still yet even more commonly about 80%, still yet even more commonlyabout 85%, still yet even more commonly about 90%, still yet even morecommonly about 95%, or still yet even more commonly about 98%.

In some embodiments, the helium-containing reservoir 100 can usuallyhave a helium saturate level of from one of about 2% or more, moreusually of about 5% or more, even more usually of about 10% or more, yeteven more usually of about 20% or more, still yet even more usuallyabout 30% or more, still yet even more usually about 40% or more, stillyet even more usually about 50% or more, still yet even more usuallyabout 50% or more, or yet even more usually about 60% or more tocommonly one of no more than about 10%, more commonly of no more thanabout 20%, even more commonly of no more than about 30%, yet even morecommonly of no more than about 40%, still yet even more commonly of nomore than about 50%, still yet even more commonly of no more than about60%, still yet even more commonly of no more than about 70%, still yeteven more commonly of no more than about 80%, still yet even morecommonly of no more than about 90%, still yet even more commonly of nomore than about 92%, still yet even more commonly of no more than about95%, or yet still even more commonly of no more than about 98%.Typically, the helium-containing reservoirs having a helium saturationvalue of one of between about 2%, more typically about 5%, even moretypically about 10%, yet even more typically about 15%, still yet evenmore typically about 20%, still yet even more typically about 25%, stillyet even more typically about 30%, still yet even more typically about35%, still yet even more typically about 40%, still yet even moretypically about 45%, still yet even more typically about 50%, still yeteven more typically about 55%, still yet or yet still even moretypically about 60% and one of generally about 15%, more generally about20%, even more generally about 25%, yet even more generally about 30%,still yet even more generally about 35%, still yet even more typicallyabout 40%, still yet even more generally about 45%, still yet even moregenerally about 50%, still yet even more generally about 55%, still yeteven more generally about 60%, still yet even more generally about 65%,still yet even more generally about 70%, still yet even more generallyabout 75%, still yet even more generally about 80%, still yet even moregenerally about 85%, still yet even more generally about 90%, still yeteven more generally about 95%, or still yet even more generally about98%.

Commonly, such production on a mass-to-mass basis processes for eachpart of the discrete helium phases 137 one part water, more commonly twoparts water, even more commonly three parts water, yet even morecommonly four parts water, still yet even more commonly five partswater, still yet even more commonly six parts water, still yet even morecommonly seven parts water, still yet even more commonly eight partswater, still yet even more commonly nine parts water, still yet evenmore commonly ten parts water, still yet even more commonly eleven partswater, still yet even more commonly twelve parts water, still yet evenmore commonly thirteen parts water, still yet even more commonlyfourteen parts water, still yet even more commonly fifteen parts water,still yet even more commonly sixteen parts water, still yet even morecommonly seventeen parts water, still yet even more commonly eighteenparts water, still yet even more commonly nineteen parts water, stillyet even more commonly twenty parts water, still yet even more commonlytwenty-one parts water, still yet even more commonly twenty-two partswater, still yet even more commonly twenty-three parts water, still yeteven more commonly twenty-four parts water, still yet even more commonlytwenty-five parts water, still yet even more commonly twenty-six partswater, still yet even more commonly twenty-seven parts water, still yeteven more commonly twenty-eight parts water, still yet even morecommonly twenty-nine parts water, or yet still even more commonly thirtyparts water.

FIG. 4 depicts process 150 for treating a helium-containing reservoirhaving a high moveable water saturation and a plurality of discretehelium phases 137.

The target well generally traverses a helium-containing reservoir havinga high moveable water saturation and a plurality of discrete heliumphases 137. The target well can have a water to a gaseous helium ratio.The target well typically can have a first water to gaseous heliumratio.

In some embodiments, the first water to gaseous helium ratio isgenerally one of its historical water to gaseous helium production ratioor its original water to gaseous hydro-carbon ratio when it wasoriginally put into production. Commonly, the first water to gaseoushelium ratio of the target well is one of about from about 10⁻³ to about10³, more commonly from about 10⁻² to about 10³, even more commonlyabout 10⁻³ to about 10², yet even more commonly about 10⁻² to about 10²,still yet even more commonly about 10⁻¹ to about 10², still yet evenmore commonly about 10⁻² to about 10¹, or yet still even more commonlyabout 10⁻¹ to about 10¹.

In some embodiments, the first water to gaseous helium ratio isgenerally one of its historical water to gaseous helium production ratioor its original water to gaseous helium ratio when it was originally putinto production. Commonly, the first water to gaseous helium ratio ofthe target well is from one of about 1 bbl water per 1000 MCF gaseoushelium, more commonly of about 10 bbl water per 1000 MCF, even morecommonly of about 20 bbl of water per 1000 MCF, yet even more commonlyof about 50 bbl water per 1000 MCF, still yet even more commonly ofabout 100 bbl of water per 1000 MCF, still yet even more commonly ofabout 200 bbl of water per 1000 MCF, still yet even more commonly ofabout 500 bbl of water per 1000 MCF, or yet still even more commonly ofabout 1000 bbl of water per 1000 MCF of gaseous helium to one oftypically about 2000 bbl water per 1000 MCF gaseous helium, moretypically of about 1750 bbl water per 1000 MCF, yet even more typicallyof about 1500 bbl of water per 1000 MCF, still yet even more typicallyabout 1250 bbl of water per 1000 MCF, still yet even more typicallyabout 1000 bbl of water per 1000 MCF, still yet even more typicallyabout 500 bbl of water per 1000 MCF, still yet even more typically about200 bbl of water per 1000 MCF, or yet still even more typically about100 bbl of water per 1000 MCF of gaseous helium.

It can be appreciated that the target well can be identified by one ormore of its production and well log characteristics. For example, asdescribed above, the target well produces substantially more water thanhelium and has a well log indicating high levels of moveable watercompared to helium saturate levels as detailed above.

In step 152, the process 150 can include a step of providing a gas. Theprovided gas can be any gas. The provided gas can be substantially asingle chemical composition or a mixture of chemical compositions.Moreover, the provided gas can be an inorganic composition, an organiccomposition, a mixture of inorganic compositions, a mixture of organiccompositions, or combinate of inorganic and organic compositions. Inaccordance with some embodiments of the disclosure, the provided gas canbe an inert gas. In accordance with some embodiments of the disclosure,the provided gas can be nitrogen (N₂). In accordance with someembodiments of the disclosure, the provided gas can be hydrogen (H₂). Inaccordance with some embodiments of the disclosure, the provided gas canbe methane (CH₄). In accordance with some embodiments of the disclosure,the provided gas can be ethane (CH₃—CH₃). In accordance with someembodiments of the disclosure, the provided gas can be propane (C₃H₈).In accordance with some embodiments of the disclosure, the provided gascan be butane (C₄H₁₀). In accordance with some embodiments of thedisclosure, the provided gas can be carbon dioxide (CO₂). In accordancewith some embodiments of the disclosure, the provided gas can be one ormore of nitrogen (N₂), hydrogen (H₂), methane (CH₄), ethane (CH₃—CH₃),propane (C₃H₈), butane (C₄H₁₀), carbon dioxide (CO₂), and inert gas.Moreover, while not wanting to be limited by example, the provided gascan be in some embodiments air, oxygen, nitrogen, an inert gas, carbondioxide, methane, ethane, propane, iso-propane, butane, isobutane,t-butane, pentane, iso-pentane, t-pentane, or a mixture thereof. Theprovided gas can be provided by a commercial source, a subterraneansource, an atmospheric source, or a combination thereof. In accordancewith some embodiments, an injection gas (such as, but not limited tomethane or methane and an associated hydrocarbon) can be injected into ahelium-containing reservoir.

In step 153, the provided gas can be injected into the target well. Thetarget well can traverse a subterranean helium-containing reservoir 100.Moreover, the provided gas can be injected into the subterraneanhelium-containing reservoir 100. In accordance with some embodiments ofthe disclosure, the injection step 153 can include the provided gasbeing in the gas phase during the injection of the gas into the wellbore. A person of ordinary skill in the art would generally consider theprocess 100 described herein of injecting a provided gas into a watersaturated helium-containing reservoir counter-intuitive. Morespecifically, a person of ordinary skill in the art would considerinjecting a provided gas into a water saturated helium-containingreservoir to one or both of dewater the reservoir and improve heliumrecovery from the reservoir.

In accordance with some embodiments of the disclosure, the injectionstep 153 can include the provided gas being in the liquid phase whenbeing injected into the well bore. In accordance with some embodimentsof the disclosure, the injection step 153 can include the provided gasbeing in the form of a foam when being injected into the well bore.Moreover, in accordance with some embodiments of the disclosure, theinjection step 153 can include the provided gas being in the form of oneor more of gas phase, liquid phase, foam, or combination thereof whenbeing injected into the well bore. In some embodiments, the foam can bemore gas by volume than liquid by volume. Moreover, in some embodimentsthe foam can have no more than about 50 volume % liquid. Furthermore, inaccordance with some embodiments, the foam can have less gas by volumethan liquid by volume.

The subterranean helium-containing reservoir 100 generally comprises areservoir having a high moveable water saturation and a plurality ofdiscreet helium phases 137 for a period. Typically, the provided gas canbe injected into the subterranean helium-containing reservoir 100 at arate of from one of about 10 mcfd or more, more typically at a rate ofabout 20 mcfd or more, even more typically at a rate of about 30 mcfd ormore, yet even more typically at a rate of about 40 mcfd or more, stillyet even more typically at a rate of about 50 mcfd or more, still yeteven more typically at a rate of about 60 mcfd or more, still yet evenmore typically at a rate of about 70 mcfd or more, still yet even moretypically at a rate of about 80 mcfd or more, still yet even moretypically at a rate of about 90 mcfd or more, still yet even moretypically at a rate of about 100 mcfd or more, still yet even moretypically at a rate about 110 mcfd or more, still yet even moretypically at a rate least about 120 mcfd or more, still yet even moretypically at a rate of about 130 mcfd or more, still yet even moretypically at a rate of about 140 mcfd or more, still yet even moretypically at a rate of about 150 mcfd or more, still yet even moretypically at a rate of about 160 mcfd or more, still yet even moretypically at a rate of about 170 mcfd or more, still yet even moretypically at a rate of about 180 mcfd or more, still yet even moretypically at a rate of about 190 mcfd or more, still yet even moretypically at a rate of about 200 mcfd or more, still yet even moretypically at a rate of about 210 mcfd or more, still yet even moretypically at a rate of about 220 mcfd or more, still yet even moretypically at a rate of about 230 mcfd or more, still yet even moretypically at a rate of about 240 mcfd or more, still yet even moretypically at a rate of about 250 mcfd or more, still yet even moretypically at a rate of about 260 mcfd or more, still yet even moretypically at a rate of about 270 mcfd or more, still yet even moretypically at a rate of about 280 mcfd or more, still yet even moretypically at a rate of about 290 mcfd or more, still yet even moretypically at a rate of about 300 mcfd or more, still yet even moretypically at a rate of about 310 mcfd or more, still yet even moretypically at a rate of about 320 mcfd or more, still yet even moretypically at a rate of about 330 mcfd or more, still yet even moretypically at a rate of about 340 mcfd or more, still yet even moretypically at a rate of about 350 mcfd or more, still yet even moretypically at a rate of about 360 mcfd or more, still yet even moretypically at a rate of about 370 mcfd or more, still yet even moretypically at a rate of about 380 mcfd or more, still yet even moretypically at a rate of about 390 mcfd or more, still yet even moretypically at a rate of about 400 mcfd or more, still yet even moretypically at a rate of about 410 mcfd or more, still yet even moretypically at a rate of about 420 mcfd or more, still yet even moretypically at a rate of about 430 mcfd or more, still yet even moretypically at a rate of about 440 mcfd or more, still yet even moretypically at a rate of about 450 mcfd or more, still yet even moretypically at a rate of about 460 mcfd or more, still yet even moretypically at a rate of about 470 mcfd or more, still yet even moretypically at a rate of about 480 mcfd or more, still yet even moretypically at a rate of about 490 mcfd or more, still yet even moretypically at a rate of about 500 mcfd or more, still yet even moretypically at a rate of about 510 mcfd or more, still yet even moretypically at a rate of about 520 mcfd or more, still yet even moretypically at a rate of about 530 mcfd or more, still yet even moretypically at a rate of about 540 mcfd or more, still yet even moretypically at a rate of about 550 mcfd or more, still yet even moretypically at a rate of about 560 mcfd or more, still yet even moretypically at a rate of about 570 mcfd or more, still yet even moretypically at a rate of about 580 mcfd or more, still yet even moretypically at a rate of about 590 mcfd or more, still yet even moretypically at a rate least about 600 mcfd or more, still yet even moretypically at a rate of about 610 mcfd or more, still yet even moretypically at a rate of about 620 mcfd or more, still yet even moretypically at a rate of about 630 mcfd or more, still yet even moretypically at a rate of about 640 mcfd or more, still yet even moretypically at a rate of about 650 mcfd or more, still yet even moretypically at a rate of about 660 mcfd or more, still yet even moretypically at a rate of about 670 mcfd or more, still yet even moretypically at a rate of about 680 mcfd or more, still yet even moretypically at a rate of about 690 mcfd or more, still yet even moretypically at a rate of about 700 mcfd or more, still yet even moretypically at a rate of about 710 mcfd or more, still yet even moretypically at a rate of about 720 mcfd or more, still yet even moretypically at a rate of about 730 mcfd or more, still yet even moretypically at a rate of about 740 mcfd or more, still yet even moretypically at a rate of about 750 mcfd or more, still yet even moretypically at a rate of about 760 mcfd or more, still yet even moretypically at a rate of about 770 mcfd or more, still yet even moretypically at a rate of about 780 mcfd or more, still yet even moretypically at a rate of about 790 mcfd or more, still yet even moretypically at a rate of about 800 mcfd or more, still yet even moretypically at a rate of about 810 mcfd or more, still yet even moretypically at a rate of about 820 mcfd or more, still yet even moretypically at a rate of about 830 mcfd or more, still yet even moretypically at a rate of about 840 mcfd or more, still yet even moretypically at a rate of about 850 mcfd or more, still yet even moretypically at a rate of about 860 mcfd or more, still yet even moretypically at a rate of about 870 mcfd or more, still yet even moretypically at a rate of about 880 mcfd or more, still yet even moretypically at a rate of about 890 mcfd or more, still yet even moretypically at a rate of about 900 mcfd or more, still yet even moretypically at a rate of about 910 mcfd or more, still yet even moretypically at a rate of about 920 mcfd or more, still yet even moretypically at a rate of about 930 mcfd or more, still yet even moretypically at a rate of about 940 mcfd or more, still yet even moretypically at a rate of about 950 mcfd or more, still yet even moretypically at a rate of about 960 mcfd or more, still yet even moretypically at a rate of about 970 mcfd or more, still yet even moretypically still yet even more typically at a rate of about 980 mcfd ormore, still yet even more typically at a rate of about 990 mcfd or more,yet still even more typically at a rate of about 1,000 mcfd or more, toone of commonly no more than about more commonly at a rate of no morethan about 20 mcfd, even more commonly at a rate of no more than about30 mcfd, yet even more commonly at a rate of no more than about 40 mcfd,still yet even more commonly at a rate of no more than about 50 mcfd,still yet even more commonly at a rate of no more than about 60 mcfd,still yet even more commonly at a rate of no more than about 70 mcfd,still yet even more commonly at a rate of no more than about 80 mcfd,still yet even more commonly at a rate of no more than about 90 mcfd,still yet even more commonly at a rate of no more than about 100 mcfd,still yet even more commonly at a rate about 110 mcfd, still yet evenmore commonly at a rate least about 120 mcfd, still yet even morecommonly at a rate of no more than about 130 mcfd, still yet even morecommonly at a rate of no more than about 140 mcfd, still yet even morecommonly at a rate of no more than about 150 mcfd, still yet even morecommonly at a rate of no more than about 160 mcfd, still yet even morecommonly at a rate of no more than about 170 mcfd, still yet even morecommonly at a rate of no more than about 180 mcfd, still yet even morecommonly at a rate of no more than about 190 mcfd, still yet even morecommonly at a rate of no more than about 200 mcfd, still yet even morecommonly at a rate of no more than about 210 mcfd, at a rate of no morethan about 220 mcfd, still yet even more commonly at a rate of no morethan about 230 mcfd, still yet even more commonly at a rate of no morethan about 240 mcfd, at a rate of no more than about 250 mcfd, still yeteven more commonly at a rate of no more than about 260 mcfd, still yeteven more commonly at a rate of no more than about 270 mcfd, still yeteven more commonly at a rate of no more than about 280 mcfd, still yeteven more commonly at a rate of no more than about 290 mcfd, still yeteven more commonly at a rate of no more than about 300 mcfd, still yeteven more commonly at a rate of no more than about 310 mcfd, still yeteven more commonly at a rate of no more than about 320 mcfd, still yeteven more commonly at a rate of no more than about 330 mcfd, still yeteven more commonly at a rate of no more than about 340 mcfd, still yeteven more commonly at a rate of no more than about 350 mcfd, at a rateof no more than about 360 mcfd, still yet even more commonly at a rateof no more than about 370 mcfd, at a rate of no more than about 380mcfd, at a rate of no more than about 390 mcfd, still yet even morecommonly at a rate of no more than about 400 mcfd, at a rate of no morethan about 410 mcfd, still yet even more commonly at a rate of no morethan about 420 mcfd, still yet even more commonly at a rate of about 430mcfd, still yet even more commonly at a rate of no more than about 440mcfd, at a rate of no more than about 450 mcfd, still yet even morecommonly at a rate of no more than about 460 mcfd, still yet even morecommonly at a rate of no more than about 470 mcfd, still yet even morecommonly at a rate of no more than about 480 mcfd, still yet even morecommonly at a rate of no more than about 490 mcfd, still yet even morecommonly at a rate of no more than about 500 mcfd, still yet even morecommonly at a rate of no more than about 510 mcfd, still yet even morecommonly at a rate of no more than about 520 mcfd, still yet even morecommonly at a rate of no more than about 530 mcfd, still yet even morecommonly at a rate of no more than about 540 mcfd, still yet even morecommonly at a rate of no more than about 550 mcfd, at a rate of no morethan about 560 mcfd, at a rate of no more than about 570 mcfd, still yeteven more commonly at a rate of no more than about 580 mcfd, still yeteven more commonly at a rate of no more than about 590 mcfd, still yeteven more commonly at a rate least about 600 mcfd, still yet even morecommonly at a rate of no more than about 610 mcfd, still yet even morecommonly at a rate of no more than about 620 mcfd, still yet even morecommonly at a rate of no more than about 630 mcfd, still yet even morecommonly at a rate of no more than about 640 mcfd, still yet even morecommonly at a rate of no more than about 650 mcfd, still yet even morecommonly at a rate of no more than about 660 mcfd, still yet even morecommonly at a rate of no more than about 670 mcfd, still yet even morecommonly at a rate of no more than about 680 mcfd, at a rate of no morethan about 690 mcfd, at a rate of no more than about 700 mcfd, still yeteven more commonly at a rate of no more than about 710 mcfd, at a rateof no more than about 720 mcfd, at a rate of no more than about 730mcfd, still yet even more commonly at a rate of no more than about 740mcfd, still yet even more commonly at a rate of no more than about 750mcfd, still yet even more commonly at a rate of no more than about 760mcfd, still yet even more commonly at a rate of no more than about 770mcfd, still yet even more commonly at a rate of no more than about 780mcfd, still yet even more commonly at a rate of no more than about 790mcfd, still yet even more commonly at a rate of no more than about 800mcfd, still yet even more commonly at a rate of no more than about 810mcfd, still yet even more commonly at a rate of no more than about 820mcfd, still yet even more commonly at a rate of no more than about 830mcfd, still yet even more commonly at a rate of no more than about 840mcfd, still yet even more commonly at a rate of no more than about 850mcfd, still yet even more commonly at a rate of no more than about 860mcfd, still yet even more commonly at a rate of no more than about 870mcfd, still yet even more commonly at a rate of no more than about 880mcfd, still yet even more commonly at a rate of no more than about 890mcfd, still yet even more commonly at a rate of no more than about 900mcfd, still yet even more commonly at a rate of no more than about 910mcfd, still yet even more commonly at a rate of no more than about 920mcfd, still yet even more commonly at a rate of no more than about 930mcfd, still yet even more commonly at a rate of no more than about 940mcfd, still yet even more commonly at a rate of no more than about 950mcfd, still yet even more commonly at a rate of no more than about 960mcfd, at a rate of no more than about 970 mcfd, still yet even morecommonly at a rate of no more than about 980 mcfd, still yet even morecommonly at a rate of no more than about 990 mcfd, still yet even morecommonly at a rate of no more than about 1,000 mcfd, still yet even morecommonly at a rate of no more than about 1,100 mcfd, still yet even morecommonly at a rate of no more than about 1,250 mcfd, still yet even morecommonly at a rate of no more than about 1,500 mcfd, still yet even morecommonly at a rate of no more than about 2,000 mcfd, still yet even morecommonly at a rate of no more than about 2,500 mcfd, still yet even morecommonly at a rate of no more than about 3,000 mcfd, still yet even morecommonly at a rate of no more than about 3,500 mcfd, still yet even morecommonly at a rate of no more than about 4,000 mcfd, still yet even morecommonly at a rate of no more than about 4,500 mcfd, still yet even morecommonly at a rate of no more than about 5,000 mcfd, still yet even morecommonly at a rate of no more than about 5,500 mcfd, still yet even morecommonly at a rate of no more than about 6,000 mcfd, still yet even morecommonly at a rate of no more than about 6,500 mcfd, still yet even morecommonly at a rate of no more than about 7,000 mcfd, still yet even morecommonly at a rate of no more than about 7,500 mcfd, or yet still evenmore commonly at a rate of no more than about 8,000 mcfd.

In some embodiments of the present disclosure, the provided gas isusually injected at a pressure below the reservoir fracture gradientpressure. Injection period will be for about three months, moretypically between three months and three years. In some embodiments, theinjection period is more than about 5 days but less than about threemonths. In some embodiments, the injection period is selected from thegroup of about 5 days, about 10 days, about 15 days, about 30 days,about 45 days, about 60 days, about 75 days, about 90, or anycombination thereof. In some embodiments, the provided gas can beinjected for a period of about one day. More commonly, the provided gascan be injected one of for a period of time of more than about one daybut less than about one week, even more commonly for a period of time ofmore than about one week but less than about one month, yet even morecommonly for a period of time of more than about one month but less thanabout three months, still yet even more commonly for a period of time ofmore than two months but less than about 6 months, still yet even morecommonly for a period of time of more than three months but less thanabout one year, still yet even more commonly for a period of more thanabout 6 months but less than about 18 months, still yet even morecommonly for a period of time more than about 18 months but less thanabout 24 months, still yet even more commonly for a period of more thanabout 18 months but less than 36 months, still yet even more commonlyfor a period of time of more than about two years but less than aboutfour years, or yet still even more commonly for a period of more thanabout three years but less than about 10 years.

While not wanting to be bound by any theory, it is believed that theinjection of the provided gas into the helium-containing reservoir cancoalesce one or more of the plurality of discrete helium phases 137 inthe reservoir to form one or more continuous helium phases 161, see FIG.5. It can be appreciated that as the injection of the provided gas instep 153 is maintained, the one or more the plurality of discrete heliumphases 137 can continue to coalesce. In accordance with someembodiments, the plurality of discrete helium phases 137 can be in theform one or more of pockets and bubbles of helium. Moreover, these oneor more pockets and bubbles of helium can continue coalesce to form thecontinuous helium phases 161 of helium. While not wanting to be limitedby theory, it is believed that once a more continuous helium phase 161is formed within the reservoir, the helium along with the provided gascan flow toward the well bore.

Injection of the provided gas into the reservoir, in step 153, canimbibe the injected gas into the pore volumes 120. It can be appreciatedthat the pore volumes comprise a network of pores within the reservoir.Moreover, the network of pores within the reservoir have a porosity andpermeability. As used herein, porosity generally relates to void spacesin the subterranean helium-containing reservoir 100 that can holdfluids. As used herein, permeability generally relates to acharacteristic of the subterranean helium-containing reservoir 100 thatfluid to through the rock. As can be appreciated, permeability isgenerally a measure of the interconnectivity of the void spaces(porosity) and their size.

The provided gas can imbibe the helium-containing reservoir. Moreover,the provided gas can coalesce with the helium contained in thehelium-containing reservoir to form a one or more continuous heliumphases 161 within the reservoir.

While not wanting to be limited by theory, it is believed that the oneor more continuous helium phases 161 commonly span two or more porevolumes 120 defined by the reservoir materials 110, more commonly threeor more pore volumes 120, or even more commonly four or more porevolumes 120. This is generally in contrast to the each of the pluralityof discrete helium phases 137 which typically occupy a single porevolume 120. The injection of the provided gas can increase the degree ofhelium saturation of the helium-containing reservoir. Moreover, theinjection of the provided gas into the reservoir generally decreases thedegree of water saturation of helium-containing reservoir.

After a period of injecting the provided gas (in step 153), the targetwell can be logged in step 154. In some embodiments, the target well isnot logged but put into production, step 155, after a targeted volume ofthe provided gas has been injected. Typically, production step 155comprises reversing flow of the target well. That is, the injection step153 is ceased and the flow of gas is reversed from injecting toproducing. The production step 155 generally includes gathering from thesubterranean helium-containing reservoir 100 the injected provided gasand the helium contained within the helium-containing reservoir.Management of the production step 155 generally depends on reservoirrock properties and conditions. It can be appreciated that the flow ofthe helium towards the well bore resumes producing operations of thetarget well.

In some embodiments, if the well log indicates that the level moveablewater saturation has decreased commonly by an amount of one of about10%, more commonly by about 20%, even more commonly by about 30%, yeteven more commonly by about 40%, still yet more commonly by about 50%,still yet more commonly by about 60%, still yet more commonly by about70%, still yet more commonly by about 80%, still yet more commonly byabout 90% or yet still more commonly by about 95% or more, the well canbe put into production, step 155. In some embodiments, the well log canindicate the level of moveable water saturation has decreased bygenerally by amount from about one of about 5% or more, more generallyof about 10% or more, even more generally of about 15% or more, yet evenmore generally of about 20% or more, still yet even more generally about25% or more, still yet even more generally about 30% or more, still yeteven more generally about 40% or more, still yet even more generallyabout 50% or more, or yet even more generally about 60% or more totypically one of no more than about 10%, more typically of no more thanabout 20%, even more typically of no more than about 30%, yet even moretypically of no more than about 40%, still yet even more typically of nomore than about 50%, still yet even more typically of no more than about60%, still yet even more typically of no more than about 70%, still yeteven more typically of no more than about 80%, still yet even moretypically of no more than about 90%, still yet even more typically of nomore than about 92%, still yet even more typically of no more than about95%, or yet still even more typically of no more than about 98%.Generally, it is believed that the decrease in moveable water saturationcan increase the production of helium. More generally, it is believedthat the decrease in moveable water saturation can increase theproduction of gaseous helium.

In some embodiments, the well long indicates that the level heliumsaturation has increased generally by an amount, compared to its initialhelium saturation level prior to the injection of the provided gas, ofone of about 10%, more generally by about 20%, even more generally byabout 30%, yet even more general by about 40%, still yet even moregenerally by about 50%, still yet even more generally by about 60%,still yet even more generally by about 70%, still yet even moregenerally by about 80%, still yet even more generally by about 90%,still yet even more generally by about 100%, still yet even moregenerally by about 110%, still yet even more generally by about 125%, oryet still even more generally by about 130% or more. In someembodiments, the well long indicates that the level helium saturationhas increased typically by an amount, compared to its initial heliumsaturation level prior to the injection of the provided gas, from one ofabout 5%, more typically 10%, even more typically about 15%, yet evenmore typically about 20%, still yet even more typically about 25%, stillyet even more typically about 30%, still yet even more typically about35%, still yet even more typically about 40%, still yet even moretypically about 45%, still yet even more typically about 50%, still yeteven more typically about 55%, still yet even more typically about 55%,still yet even more typically about 65%, still yet even more typicallyabout 65%, still yet even more typically about 70%, still yet even moretypically about 75%, still yet even more typically about 80%, still yeteven more typically about 85%, still yet even more typically about 90%,still yet even more typically about 100%, still yet even more typicallyabout 125%, still yet even more typically about 150%, still yet evenmore typically about 175%, or yet still even more typically about 200%to one of generally about 10%, even more generally about 20%, yet evenmore generally about 30%, still yet even more generally about 40%, stillyet even more generally about 50%, still yet even more generally about60%, still yet even more generally about 70%, still yet even moregenerally about 80%, still yet even more generally about 90%, still yeteven more generally about 100%, still yet even more generally about125%, still yet even more generally about 150%, still yet even moregenerally about 175%, still yet even more generally about 200%, stillyet even more generally about 250%, still yet even more generally about300%, still yet even more generally about 350%, still yet even moregenerally about 400%, still yet even more generally about 450%, stillyet even more generally about 500%, still yet even more generally about550%, still yet even more generally about 600%, or yet still even moregenerally about 700%.

The well can be put into production, step 155. The target well, afterthe injection of provided gas, generally can have a second water togaseous helium ratio. The second water to gaseous helium ratio isgenerally less than the first water to gaseous helium ratio. Commonly,the second water to gaseous helium ratio is typically from about one ofno more than about 98% of the first water to gaseous helium ratio, moretypically no more than about 95%, even more typically no more than about90%, yet even more typically no more than about 85%, still yet even moretypically no more than about 80%, still yet even more typically no morethan about 75%, still yet even more typically no more than about 60%,still yet even more typically no more than about 55%, still yet evenmore typically no more than about 50%, still yet even more typically nomore than about 45%, or yet still even more typically no more than about40% of the first water to gaseous helium ratio to one of commonly about2% or more of the first water to gaseous helium ratio, more commonlyabout 5% or more, even more commonly about 10% or more, yet even morecommonly about 15% or more, still yet even more commonly about 20% ormore, still yet even more commonly about 25% or more, still yet evenmore commonly about 30% or more, still yet even more commonly about 35%or more, still yet even more commonly about 40% or more, still yet evenmore commonly about 45% or more, still yet even more commonly about 50%or more, still yet even more commonly about 55% or more, still yet evenmore commonly about 60% or more, still yet even more commonly about 65%or more, still yet even more commonly about 70% or more, still yet evenmore commonly about 75% or more, still yet even more commonly about 80%or more, still yet even more commonly about 85% or more, or yet stilleven more commonly about 90% or more of the first water to gaseoushelium ratio.

It is commonly believed that the increase in helium saturation canincrease the production of helium

If the well log does not indication that one or more of that the levelof moveable water saturation has substantially decreased, the level ofhelium saturation has substantially increased sufficiently or acombination thereof, the injection of the provided gas in step 153 canbe continued or the process 150 can be ceased.

Helium production, step 155, can be continued until one or more of thefollowing is true: (a) the well ceases to produce any more helium; (b)the level of water production becomes unsatisfactory; and (c) thehelium-containing reservoir becomes water saturated again. In someembodiments, if one or more of (a), (b) or (c) are true, process 150 canbe ceased, step 156. In some embodiments, if one or more of (a), (b) or(c) are true, the provided gas injection step 153 can be reinitiated. Insome embodiments, if one or more of (a), (b) or (c) are true the wellcan be logged again to determine one or more of the moveable water andhelium saturation levels. If the helium saturation level indicatesenough helium is available for recovery, the provided gas injection stepcan be reinitiated.

It is believed that the injection of the provided gas into thehelium-containing reservoir to coalesce one or more of the plurality ofdiscrete helium phases 137 in the reservoir to form one or morecontinuous helium phases 161 differs from the injection of carbondioxide or other similar gas to lower the viscosity of entrained helium.The injection of the provided gas and coalesce of the one or more of theplurality of discrete helium phases 137 is not believed to be due tochange in viscosity of the discrete helium phases 157. What, if anychange, in the viscosity of the injected provided gas, the discreethelium phases 157 and the one or more continuous helium phases 161 arebelieve negligible.

FIG. 6 depicts a method of recovering helium from a helium-containingreservoir, where illustrative steps for the method are shown along anaxis of time. In FIG. 6, a producing gas (e.g., nitrogen) is injected tothe helium-containing formation for a period at 610, from time T1 totime T2. Following time T2, the well may be shut-in for a dwell timefrom T2 to T3. Then, the gas may be reproduced out of the well from timeT3 to time T4 to obtain the helium gas.

FIG. 7 depicts coalescence of two gases. In FIG. 7, a bubble of nitrogengas 710 coexists with (e.g., is adjacent to) a bubble of helium gas 715.At 720, the nitrogen gas coalesces with the helium gas. At 730, there isa coalesced bubble of nitrogen gas and helium gas.

In various embodiments, even in helium containing reservoirs (e.g.,underground formations and/or aquifers), containing small amounts ofhelium (e.g., less than about 1% by volume), coalescing of the heliumgas with a provided gas can provide an economically feasible method ofproducing helium. For example, in a 100-foot mining zone having an about17% porosity, a helium concentration of about 0.5% by volume, and anabout 50% recovery by volume, an economically advantageous amount ofhelium may be recovered using the methods and systems disclosed herein.For about 15% to about 25% gas saturation, there may be about 5,500 mcfof helium per section, which may result in about 6 to about 10 billioncubic feet (bcf) of recoverable helium. Such recovery may provide anundiscounted gross resource value of about one billion US dollars inhelium and an undiscounted gross resource value of about one billion USdollars in natural gas, which would result in a total undiscountedresource value of about two billion US dollars. These illustrativeestimates assume a one dollar per mcf for natural gas after processingthe low BTU (e.g., nitrogen) comingled gas.

Various embodiments of the present disclosure are discussed in thefollowing attachment, which is incorporated herein fully by thisreference: Exhibit “A” (2 pages).

The present disclosure, in various aspects, embodiments, andconfigurations, includes components, methods, processes, systems and/orapparatus substantially as depicted and described herein, includingvarious aspects, embodiments, configurations, sub-combinations, andsubsets thereof. Those of skill in the art will understand how to makeand use the various aspects, aspects, embodiments, and configurations,after understanding the present disclosure. The present disclosure, invarious aspects, embodiments, and configurations, includes providingdevices and processes in the absence of items not depicted and/ordescribed herein or in various aspects, embodiments, and configurationshereof, including in the absence of such items as may have been used inprevious devices or processes, e.g., for improving performance,achieving ease and/or reducing cost of implementation.

The foregoing discussion of the disclosure has been presented forpurposes of illustration and description. The foregoing is not intendedto limit the disclosure to the form or forms disclosed herein. In theforegoing Detailed Description for example, various features of thedisclosure are grouped together in one or more, aspects, embodiments,and configurations for streamlining the disclosure. The features of theaspects, embodiments, and configurations of the disclosure may becombined in alternate aspects, embodiments, and configurations otherthan those discussed above. This method of disclosure is not to beinterpreted as reflecting an intention that the claimed disclosurerequires more features than are expressly recited in each claim. Rather,as the following claims reflect, inventive aspects lie in less than allfeatures of a single foregoing disclosed aspects, embodiments, andconfigurations. Thus, the following claims are hereby incorporated intothis Detailed Description, with each claim standing on its own as aseparate preferred embodiment of the disclosure.

Moreover, though the description of the disclosure has includeddescription of one or more aspects, embodiments, or configurations andcertain variations and modifications, other variations, combinations,and modifications are within the scope of the disclosure, e.g., as maybe within the skill and knowledge of those in the art, afterunderstanding the present disclosure. It is intended to obtain rightswhich include alternative aspects, embodiments, and configurations tothe extent permitted, including alternate, interchangeable and/orequivalent structures, functions, ranges or steps to those claimed,whether such alternate, interchangeable and/or equivalent structures,functions, ranges or steps are disclosed herein, and without intendingto publicly dedicate any patentable subject matter.

1. A method, comprising: injecting a provided gas into a well bore influid communication with a helium-containing reservoir; ceasing theinjection of the provided gas into the selected well bore; gatheringtogether from the helium-containing reservoir by the selected well boresome of the provided gas and some of the helium to form a gathered-gasmixture comprising the provided gas and some of the helium from thehelium-containing reservoir; and producing through the selected wellbore the gathered-gas mixture.
 2. The method of claim 1, wherein thehelium-containing reservoir has a moveable water saturation value ofbetween about 15% and about 90%.
 3. The method of claim 1, wherein theprovided gas is injected into the well bore at a rate of between about10 mcfd and about 8,000 mcfd.
 4. The method of claim 1, wherein thegathered-gas mixture comprises between about 0.5 vol % and about 99.5vol % of the provided gas and between about 0.5 vol % and about 99.5 vol% of helium.
 5. The method of claim 1, wherein the provided gas injectedinto the helium-containing reservoir is selected from the groupconsisting of methane, ethane, propane, nitrogen, butane, air, oxygen,argon, carbon dioxide, and mixtures thereof.
 6. The method of claim 1,wherein the helium-containing reservoir comprises at least one of aplurality of discrete helium phases and a plurality of discrete nitrogenphases prior to the injecting of the provided gas.
 7. The method ofclaim 6, wherein the helium-containing reservoir comprises a pluralityof discrete helium phases prior to the injecting of the provided gas,wherein the provided gas and one or more of the plurality of discretehelium phases coalesce to form one or more continuous phases of theprovided gas and helium during the injecting of the provided gas.
 8. Amethod, comprising: providing a gas; injecting the provided gas into aselected well bore in fluid communication with a helium-containingreservoir having a first water-to-gas production ratio, wherein theprovided gas is injected at rate of from about 10 mcfd or more to aboutno more than about 8,000 mcfd; ceasing the injection of the provided gasinto the selected well bore; gathering together from thehelium-containing reservoir by the selected well bore some of theprovided gas and some of the gaseous helium to form a gathered-gasmixture comprising the provided gas and some of the gaseous helium fromthe helium-containing reservoir; and producing through the selected wellbore the gathered-gas mixture, wherein the helium-containing reservoirproducing the gathered-gas mixture has a second water-to-gas productionratio and wherein the second water-to-gas ratio is no more than thefirst water-to-gas ratio.
 9. The method of claim 8, wherein thehelium-containing reservoir has a moveable water saturation value ofbetween about 15% and about 90%.
 10. The method of claim 8, wherein theprovided gas injected into the helium-containing reservoir is selectedfrom the group consisting of methane, ethane, propane, nitrogen, butane,air, oxygen, argon, carbon dioxide, and mixtures thereof.
 11. The methodof claim 8, wherein the gathered-gas mixture comprises between about 0.5vol % and about 99.5 vol % of the provided gas and between about 0.5 vol% and about 99.5 volume % of helium.
 12. The method of claim 8, whereinthe helium-containing reservoir comprises at least one of a plurality ofdiscrete helium phases and a plurality of discrete nitrogen phases priorto the injecting of the provided gas.
 13. The method of claim 12,wherein the helium-containing reservoir comprises a plurality ofdiscrete helium phases prior to the injecting of the provided gas,wherein the provided gas and one or more of the plurality of discretehelium phases coalesce to form one or more continuous phases of theprovided gas and helium during the injecting of the provided gas. 14.The method of claim 12, wherein the helium-containing reservoircomprises a plurality of discrete helium phases prior to the injectingof the provided gas, wherein a majority of the helium in the pluralityof discrete helium phases is in a gas phase.
 15. A method, comprising:providing a target well having a first water to gas production ratiofrom about 1 bbl water/1000 MCF to about 2000 bbl water/1000 MCF;providing a gas; injecting the provided gas into a well bore, whereinthe well bore traverses and is in fluid communication with ahelium-containing reservoir, wherein the provided gas is injected at arate of from about 10 mcfd or more to about no more than about 8,000mcfd; and producing, after the ceasing of the injection of the providedgas, from the target well at a second water to gaseous helium ratio,wherein the second water to gaseous helium ratio is from about 98% toabout 2% of first water to gas production ratio.
 16. The method of claim15, wherein the helium-containing reservoir has a moveable watersaturation value of between about 15% and about 90%.
 17. The method ofclaim 15, wherein the gathered-gas mixture comprises between about 0.5vol % and about 99.5 vol % of the provided gas and between about 0.5 vol% and about 99.5 vol % of helium.
 18. The method of claim 15, whereinthe provided gas injected into the helium-containing reservoir isselected from the group consisting of methane, ethane, propane,nitrogen, butane, air, oxygen, argon, carbon dioxide, and mixturesthereof.
 19. The method of claim 18, wherein the injecting of theprovided gas into the well bore is at a pressure below the fracturepressure of the helium-containing reservoir and wherein, immediatelybefore and after provided gas injection, at least about 75 mole % of theproduction from the well bore is helium.
 20. The method of claim 15,wherein the helium-containing reservoir comprises at least one of aplurality of discrete helium phases and a plurality of discrete nitrogenphases prior to the injecting of the provided gas.